Black-Oil Model

This project implements a Black-Oil reservoir model in Python to simulate the behavior of oil, gas, and water phases under standard black-oil assumptions. It is intended for educational purposes and as a foundation for future reservoir simulation development.

Requirements

• Python 3.10+ (It is not recommended to use the latest version)
• Dependencies listed in requirements.txt (numpy, pandas, barril)

Installation and Usage

Clone the repository and create a virtual environment:

python -m venv venv
venv\Scripts\activate
pip install -r requirements.txt

Then run the main script

python main.py

Project Structure

• main.py – main execution script
• requirements.txt – project dependencies
• venv/ – virtual environment

Correlations/Equations Used

Below are the thermodynamic correlations/equations used and their respective authors:

Gas Phase

• Gas Specific Gravity (Defined Relative to Dry Air at Standard Conditions)
• Pseudoreduced Pressure and Temperature (Defined from Pseudocritical Properties)
• Pseudocritical pressure and temperature (R. P. Sutton Correlation, 1985)
• Gas Density (Real Gas Equation of State)
• Gas Compressibility Factor (Papay Correlation, 1985)
• Gas Reduced Isothermal Compressibility (Derived from the Real Gas Equation of State)
• Gas Formation Volume Factor (Calculated from the Real Gas Equation of State under Standard Conditions)
• Gas Expansion Factor (Inverse of Gas Formation Volume Factor)
• Gas Viscosity (Lee et al. Correlation, 1966)

Oil Phase

• Oil Specific Gravity (Defined Relative to Water)
• API Gravity (Derived from Oil Specific Gravity)
• Bubble-Point Pressure (Standing Correlation, 1947)
• Solution Gas–Oil Ratio (Standing Correlation, 1947; constant above the bubble-point pressure)
• Oil Isothermal Compressibility (Standing Correlation above the bubble-point pressure; definition-based below the bubble-point pressure)
• Oil Formation Volume Factor (Exponential model above the bubble-point pressure; Standing Correlation, 1947 below the bubble-point pressure)
• Total Formation Volume Factor (Equal to the oil formation volume factor above the bubble-point pressure; includes liberated gas contribution below the bubble-point pressure)
• Oil Density (Exponential model above the bubble-point pressure; formation-volume-factor-based definition below the bubble-point pressure)
• Dead Oil Viscosity (Beal–Standing Correlation, 1981)
• Saturated Oil Viscosity (Standing Correlation, 1981; valid below the bubble-point pressure)
• Undersaturated Oil Viscosity (Beal–Standing Correlation, 1981; valid above the bubble-point pressure)

Water Phase

• Water Density (Salinity-Based Correlation at Standard Conditions)
• Gas–Water Solubility Ratio (Pressure and temperature dependent correlation)
• Water Isothermal Compressibility (Pressure, temperature, and salinity dependent correlation, valid for pressures between 1000 and 20000 psia, temperatures between 200 and 270 °F, and salinity up to 200 mg/L)
• Water Formation Volume Factor (Definition accounting for thermal expansion and pressure effects)
• Water Viscosity (Temperature and salinity dependent correlation at atmospheric pressure with pressure correction)